CARMEL, Ind. — MISO spent $1.3 million to evaluate construction bids in its first competitive transmission process, including administrative costs for issuing the request for proposals and drafting a post-selection report.
The work was funded entirely by the 11 developers that submitted proposals. Brian Pedersen, senior manager of competitive transmission, said MISO required a $100,000 deposit from each of the 11 developers to fund the cost of Duff-Coleman bid evaluation, but the RTO had to bill each of them another $21,000 to make up for all evaluation costs.
Stakeholders asked how the process could be streamlined to reduce costs.
“There aren’t a whole lot of economies to scale, since we still have to evaluate everything,” Pederson said at the March 15 Planning Advisory Committee meeting.
The RTO and stakeholders would discuss evaluation criteria and process transparency during the April meeting of the new Competitive Transmission Task Team, he said. May’s meeting will focus on possible improvements to MISO’s developer qualification process.
| MISO
Pederson also said MISO will publicly post information from Republic Transmission’s first quarterly report on the Duff-Coleman project sometime during the second quarter. (See LS Power Unit Wins MISO’s First Competitive Project.)
CAISO’s Board of Governors last week approved a measure investing the board with complete oversight authority over the grid operator’s internal Market Monitor.
“This is our response to FERC guidance on oversight of the Department of Market Monitoring,” Roger Collanton, CAISO general counsel, said during a March 15 meeting of the board. “In particular, [we’re] giving the board more direct oversight over the administrative functions of market monitoring in order to enhance the appearance and, in fact, the independence for market monitoring.”
CAISO’s Tariff currently outlines a “dual” reporting structure in which the department is subject to direct board oversight for its “core” monitoring responsibilities, while at the same time reporting to the ISO’s CEO for administrative purposes, which include budgeting and staffing matters.
The new arrangement calls for the establishment of an Oversight Committee to be staffed by governors Ashutosh Bhagwat and Angelina Galiteva. It will be charged with overseeing the department’s administration and operations, including determining staffing levels and compensation, setting departmental goals, approving budgets and ensuring that the ISO is providing adequate corporate support. The committee will operate under a newly created charter.
“The arrangement will still allow for the Department of Market Monitoring staff, as well as the director, to communicate directly with the [full] board as they need,” said Greg Fisher, senior counsel with the ISO. “However, the Oversight Committee will be something that they can reach out to for various issues.”
Hildebrandt
Fisher said the proposed changes arose out of a review of the recommendations from FERC’s audit of SPP, discussions with FERC staff currently auditing the ISO and consultation with DMM Director Eric Hildebrandt.
“I just want to emphasize that we’re very supportive of this,” Hildebrandt said. “We’re looking forward to working with the Oversight Committee, but as [Fisher] mentioned, this is really just to bring our organization in line with what FERC identified as best practices based on some other ISOs.”
Hildebrandt went on to laud CAISO CEO Steve Berberich for supporting the Monitor’s independence and for “always” having provided the necessary resources and staffing for the department. Hildebrandt called the prospect of direct engagement with the CEO and the Oversight Committee “the best of both worlds.”
“I support these [changes] under one condition, and that’s that I can continue to have that kind of relationship with [Berberich] and interface with him,” Hildebrandt said. “I think that’s very helpful in just our working as an internal Market Monitor.”
“The charter is designed with that type of flexibility in mind, so that the Oversight Committee has full ability to delegate responsibility as it sees fit to management, as well as anticipating that same type of collaboration and interaction with management,” Collanton said.
CAISO’s Board of Governors last week approved a proposal designed to prevent smaller transmission owners from footing the costs for network upgrades needed to interconnect generation serving load outside of their service territories.
Valley Electric Association serves about 18,000 customers in a sparsely populated region along the California-Nevada border. | VEA
The plan was the product of seven months of work by CAISO staff and stakeholders to address a situation facing Valley Electric Association — one that could also apply to other small utilities that join the ISO in the future. (See CAISO Issues Final Proposal for Small TO Interconnection Costs.)
Valley Electric, a Nevada-based cooperative serving about 18,000 electric customers in a sparsely populated area along the California-Nevada border, has recently been targeted as a promising site for developing solar projects intended to help California achieve its 50% by 2030 renewable portfolio standard.
Avoiding Rate Shock
“This proposal addresses the rate shock that would happen for a small [TO] and would have de minimis impact on larger [TOs],” Stephen Rutty, CAISO’s director of grid assets, told the board during its March 15 meeting.
Rutty pointed out that only a handful of CAISO stakeholders opposed the proposal, which would require the ISO to determine on a case-by-case basis whether a candidate TO could be allowed to fold low-voltage generator interconnection costs into high-voltage transmission revenue requirements, thereby spreading costs among the ISO’s entire ratepayer base. San Diego Gas and Electric demurred, citing a concern that CAISO’s solution did not meet FERC cost allocation rules.
The proposal requires that an eligible TO be very small relative to others (with a gross load of 2 million MWh or less), located in a renewable resource-rich area gaining “elevated” interest for generator procurements and not in need of the new interconnecting generation to meet an RPS.
CAISO has estimated that a single $10 million network upgrade required by new generation would increase Valley Electric’s combined high- and low-voltage transmission access charge (TAC) by nearly 14%.
“However, if they are allowed, under this proposal, to put it into their high-voltage TAC, their increase would be about 0.04%, and the rest of the [participating TOs] would see a very similar de minimis impact,” Rutty said.
150 MW New Generation vs. 130 MW Load
Valley Electric representative Josh Weber, an attorney with Davison Van Cleve, sought to provide some additional context for the board.
“Valley’s peak load, out there in the desert when the air conditioners are all running and it’s 114 degrees outside, is somewhere around 130 MW,” Weber said, adding that the cooperative is currently negotiating about 150 MW worth of generator interconnection agreements. Those deals alone could incur $6 million to $9 million in upgrade costs for the 138-kV lines that would be subject to the proposed rule.
“So that means that the generation that Valley is working hard to interconnect is much, much more than Valley’s entire peak load,” Weber said. “I think that kind of speaks to the magnitude of the cost shift that we’re talking about here.”
Speaking on behalf of the Large-scale Solar Association, California Wind Energy Association and Independent Energy Producers Association, attorney Joe Karp offered his support for the proposal.
“Several options were considered, and this option is a narrowly tailored option that addresses a unique issue,” Karp said. “We believe the solution here is consistent with general FERC and [CAISO] policy on allocating infrastructure and upgrade costs.”
Catherine Hackney, director of state legislative policy for Southern California Edison, provided an additional endorsement, saying her utility appreciated the ISO’s efforts to narrow the proposal to fit Valley Electric’s circumstances.
Cost Allocation Concerns
SoCalEd’s neighbor to the south, however, took a contrary position.
“San Diego Gas and Electric agrees with just about everybody that something needs to be done, but I think the solution here that’s been identified is, frankly, inconsistent with FERC’s policy on cost allocation,” said Jan Strack, SDG&E’s manager of transmission planning.
FERC has been “pretty clear” that costs for transmission projects should follow benefits, Strack said.
“Instead, what we have in this proposal is a one-off kind of allocation mechanism where the size of the entity suddenly takes on great weight,” he said. “Nowhere in FERC’s cost allocation principles do I see any principle that size matters.”
Strack said the ISO still needs to determine the best way to establish a linkage between benefits and costs of transmission projects.
“I think until that exercise has been gone through, it will be very premature to go forward with this one-off, unprincipled approach to allocating transmission costs just on the basis of the size of the entity,” he said.
Strack contended that all electricity users benefit from the reduced carbon emissions and lower prices fostered by new renewable generation.
“Pretty much everybody realizes benefits from these connections, so to divide this up between low- and high- [voltage] — even in the way the ISO is proposing here — is a mistake, and I don’t think it’s going to survive a test at FERC,” Strack said.
“Size was not the only criteria here,” countered Keith Casey, CAISO vice president for market and infrastructure development. “The other piece of that was that [Valley Electric] did not have an RPS [and] did not benefit from renewables connecting to its system.”
Casey agreed that FERC’s principles require costs to follow benefits, but he said that Valley Electric’s lack of benefits from the new generation would provide a “principled” argument to FERC.
He also contended that FERC must in this case consider the issue of “just and reasonable” rates.
“Imposing that cost on a small number of customers when you’re looking at a 14% increase in just one year — we think there’s an issue there around the just and reasonableness of that,” Casey said.
CARMEL, Ind. — Preliminary results of MISO and SPP’s 2016 coordinated system study are in, and the RTOs say one South Dakota project has potential even though it fails MISO’s $5 million interregional cost threshold.
Davey Lopez, MISO advisor of planning coordination and strategy, said the project — the Split Rock-Lawrence 115-kV circuit into Sioux Falls, S.D. — costs $4.56 million but is still a strong contender at a 4.79 benefit-cost ratio. The RTOs would split the benefit of the transmission project at 56% for MISO and 44% for SPP.
“This project still shows high potential to be an interregional project. … Both MISO and SPP are open to removing that hurdle,” Lopez said of MISO’s threshold. MISO won FERC approval to shed its $5 million cost minimum and 345-kV limit with PJM last year in favor of no cost floor and a 100-kV threshold. But the commission said the order did not apply to the MISO-SPP process. (See FERC Signals Bulk of NIPSCO Order Work Complete.)
The RTOs looked at seven needs for the coordinated study: two shared tie-lines, one MISO project and four SPP projects. Three of the seven possible projects are unlikely to move forward, MISO stakeholders learned at a March 15 Planning Advisory Committee meeting.
Three other projects passed joint operating agreement cost and benefit tests, but the RTOs still have reservations:
The $8 million Lyon County 345/115-kV transformer in South Dakota has a 1.14 B/C ratio and could be split 8% to MISO and 92% SPP according to regional benefit. However, MISO and SPP say those preliminary results are “highly dependent” on solar expansion in the area and said more analysis is needed before recommendation.
The $8.3 million Crosstown-Blue Valley 161-kV line in Missouri has a 3.34 B/C ratio and could be portioned 32% to MISO and 68% to SPP. SPP staff is currently evaluating whether its own solution could be more cost-effective, and MISO says that to pursue the project, it would have to revise its cost allocation process because the line is below 345 kV.
The $25 million New Brookline-James River 345-kV line and new 345/161-kV James River transformer in Missouri has a 2.06 B/C ratio and could be divided 19% to MISO and 81% to SPP. But SPP is again examining its own regional solution and MISO is testing its own regional criteria because the project is located wholly outside of MISO and because MISO’s adjusted production cost is not in synch with SPP’s.
PAC Chair Cynthia Crane said the RTOs’ mismatched adjusted production cost calculations seem to be driving a lot of MISO’s cost allocation issues.
Lopez said both RTOs will make efforts in the future to align their adjusted production cost calculation. He also said the study’s sub-345-kV projects must be regionally approved on a case-by-case basis because of the 345-kV prerequisite.
The remaining three projects in the coordinated study either failed the 5% minimum regional cost benefit percentage or the $5 million project floor. In all three cases, either MISO or SPP will continue to evaluate the projects in their own regional processes.
| MISO, SPP
More testing is needed to come up with a final list of projects, Lopez said.
The RTOs will finalize the coordinated study’s findings and publish a report in late April. At that time, the Interregional Planning Stakeholder Advisory Committee will vote on which recommended projects might proceed. The MISO side of the IPSAC vote will be conducted through the PAC.
MISO still maintains that the coordinated study will influence a longer-term joint study between the RTOs in 2017, although it’s unclear when they will work together on future interregional projects. Stakeholders learned earlier this month that a comprehensive MISO-SPP joint study is unlikely to occur in 2017. (See “Long Odds for 2nd MISO-SPP Joint Study,” SPP Briefs.)
The coordinated study was originally meant to focus on needs along SPP’s Integrated System in North Dakota, South Dakota and Iowa, and some stakeholders were doubtful that any projects would materialize. (See MISO-SPP Study Scope Finalized; Stakeholders Doubtful Projects will Result.) Last year, the IPSAC identified an initial list of high priority seams efforts for the study.
CARMEL, Ind. — The futures assumptions for MISO’s 2017 Transmission Expansion Plan are finalized, with the RTO granting its South region a different future weighting in one study.
MISO will use a 40% weighting for an existing trends future, 40% for policy regulations future and 20% for accelerated alternative technologies when conducting its market congestion planning study, which this year is focused solely on MISO South. The other studies in MTEP 17 will continue to use a 31% weighting for existing trends, 43% for policy regulations and 26% for accelerated alternative technologies.
The RTO revisited the weighting in February in response to a request from stakeholders who noted the Trump administration’s plan to eliminate the EPA Clean Power Plan. (See MISO Stakeholders Seek Review of MTEP Futures Under Trump.)
“We went through a presidential election that changed a lot of things,” MISO Director of Policy Studies J.T. Smith said at a March 15 Planning Advisory Committee meeting. “There were some concerns that, given the political climate, maybe the futures — developed in mid-2016 — didn’t quite reflect what the current situation is.”
Smith said the revisions are meant to reflect regional differences within MISO; he pointed out that MISO South transmission owners and the state regulators of southern states all asked for more emphasis on existing trends.
Both the Louisiana Public Service Commission and Arkansas Public Service Commission asked for existing trends to be given 50% consideration while policy regulations and accelerated alternative technologies receive 30% and 20% weighting, respectively. Entergy went a step further to request a 60% likelihood for existing trends, 25% for policy regulations and 15% accelerated alternative technologies.
All other MISO stakeholders that commented on futures weighting — including MISO’s coordinating, environmental and transmission developer sectors, the Iowa Utilities Board, the Indiana Utility Regulatory Commission, the Minnesota Public Utilities Commission, the Minnesota Department of Commerce, Big Rivers Electric, Midwest Power Transmission Arkansas and WPPI Energy — urged MISO to leave weighting as is.
“When we saw that regional separation, we realized that maybe there needs to be a change this year,” Smith explained, adding that the near-term nature of the market congestion planning study can better absorb a change in weighting and not affect other longer-term planning. The study is designed to identify projects to relieve congestion.
Going forward, Smith said he’d like to focus more on the probability that the generating fleet will change regardless of potential federal policy shifts. Development of MTEP 18 futures will begin at the June Planning Advisory Committee meeting, and Smith said it’s unlikely that MISO will allow divergent weightings in the next MTEP cycle.
“I still think we’re going through fleet change,” said Smith, who also admitted that “it’s uncomfortable when you change assumptions halfway through.”
Smith also said MTEP 17 weights would not change in MISO’s footprint diversity study, which is specifically designed to identify alternatives to using SPP’s transmission interface for flows between MISO South and MISO Midwest.
Some stakeholders said that conducting one MTEP study using separate future weighting is inconsistent. Others asked how MISO arrived at the altered weights. Smith said the RTO only considered comments from southern stakeholders when creating the new percentages and did not use any mathematical calculations.
Xcel Energy engineer Drew Siebenaler pointed out that most stakeholders that submitted comments on the futures supported leaving them as is. Noting that all MISO stakeholders pay for the MTEP process, he said MISO South should fund its own study if it wants to handpick assumptions.
Smith said Siebenaler’s concerns were valid and that MISO would work to improve the futures weighting process in the future.
Meanwhile, Arash Ghodsian, of MISO’s economic studies department, said the footprint diversity study and the market congestion planning study continue on track, with project candidates emerging in June. He said stakeholders submitted 58 project ideas for the market congestion planning study.
The Consumer Advocates of the PJM States (CAPS) has hired former EnerNOC executive Gregory Poulos to replace retiring Executive Director Dan Griffiths. He will transition in as Griffiths, who is expected to depart by the end of the year, leaves.
Poulos
Poulos had been at EnerNOC since 2010, rising from a manager to the director of regulatory affairs. EnerNOC provides demand response and energy management services for industrial clients. His role focused on demand response and energy-market development in PJM and MISO as well as in the states within the grid operators’ footprints.
Before EnerNOC, Poulos had stints as an assistant consumer counsel in the Office of the Ohio Consumers’ Counsel, and assistant chief of the charitable law section of the Ohio attorney general’s office.
Griffiths had worked for another DR provider, Comverge, before joining CAPS. Before Comverge, he spent seven years in the Pennsylvania Office of Consumer Advocate and 18 years at the state’s Public Utility Commission.
CAPS is made up of all state utility consumer advocate offices in the PJM region, an area spanning all or parts of 13 states and D.C. In his new role, Poulos’ duties will include being a constant presence at PJM stakeholder meetings. (See CAPS Leader Looking to Pass the Torch.)
In a news release distributed Wednesday, CAPS President Robert Mork, of the Indiana Office of Utility Consumer Counselor, cited Poulos’ “strong mix of experience and a deep understanding of the people and processes at PJM” as a major benefit for the organization.
“Dan Griffiths served our organization well as it began formal operations,” Mork said. “Hiring Greg represents the next major step as CAPS works with its members to ensure consumer interests are taken into account at PJM. Bills paid by the region’s consumers include billions of dollars in PJM charges each year, and effective participation in the PJM stakeholder process has become vital to ensuring reasonable prices and reliable power in each of our states.”
Poulos called the opportunity “a great honor” and noted the cooperative nature of the CAPS membership, despite their distance and often disparate interests.
CAPS got its initial funding from a 2012 FERC market manipulation settlement with Constellation Energy. Last year, FERC approved PJM’s creation of a funding mechanism to support the organization through a charge to residential electric customers. (See FERC Approves PJM Funding of Consumer Advocates.)
With FERC staff’s hesitant nod, MISO will apply a more stringent physical withholding rule and remove demand response and energy efficiency from market monitoring in next month’s Planning Resource Auction.
The commission released a short delegated order March 15 that accepted and suspended MISO’s proposed changes subject to refund (ER17-806).
FERC Director of Electric Power Regulation Penny Murrell, using authority delegated to her in the absence of a FERC quorum, said the commission’s preliminary review had not concluded the changes were just and reasonable and that the tentative approval was subject to further commission order.
The order will allow MISO to apply a 50-MW minimum for physical withholding rules to affiliated market participants collectively, rather than individually to each affiliated company. MISO’s Independent Market Monitor had recommended the change in its 2015 State of the Market Report, saying that as “capacity margins fall in MISO, the market will become more vulnerable to physical withholding.”
| MISO
The order also allows MISO to exempt DR, EE and external resources from PRA mitigation measures. The RTO said DR and EE resources are too small to have market power.
The rules will “provide stakeholders with greater certainty, prevent large suppliers from circumventing MISO’s mitigation provisions and encourage the participation of demand resources, energy efficiency resources and external resources” in the capacity auction, the RTO said. (See MISO Plans Additional Capacity Auction Revamps for 2017.)
A third change will allow planning resources to request facility-specific reference levels for the auction.
Reference levels are used to determine a resource’s marginal costs, including risk and opportunity costs and technical characteristics for physical offer parameters.
In its filing, MISO said its Tariff is vague as to the types of resources that can obtain a facility-specific reference level rather than using defaults. The change will permit facility-specific levels for planning resources not otherwise exempted from market mitigation.
PJM is responding to permitting delays for a 500-kV transmission line across the James River by instituting a multilayered strategy that could cost ratepayers in Virginia’s middle peninsula.
The Surry-Skiffes Creek line was proposed to maintain grid reliability on the peninsula after Dominion Energy complies on May 1 with an EPA mandate to shutter its two Yorktown coal-fired units. The project’s opponents are concerned the line would ruin the view at Jamestown and other historic sites nearby. A study conducted on behalf of the National Parks Conservation Association concluded Dominion overestimated projected power growth and called for consideration of other alternatives, including underwater lines and converting the Yorktown units to natural gas.
Proposed Yorktown pricing interface, which will expose ratepayers to high LMPs should the regional system threaten voltage collapse. | PJM
Approved by the PJM Board of Managers in 2012, the transmission project remains stalled pending permit approval from the U.S. Army Corps of Engineers. Dominion representatives have estimated construction of the line would take at least one year after all permits are approved.
Remedial Action Scheme
Opponents have dismissed as a scare tactic Dominion’s warning that failing to build the line could result in blackouts, but the company announced last month it has developed a remedial action scheme for the region that calls for dropping service to approximately 150,000 customers to prevent a potential voltage collapse from N-1-1 contingencies. (See Dominion Says Blackouts the Only Solution for Va. Peninsula.)
At a series of committee meetings last week, PJM staff detailed several other changes for the area that will have consequences protesters likely haven’t imagined.
Paul McGlynn, PJM general manager of system planning, announced at the Transmission Expansion Advisory Committee meeting that the RTO has offered Dominion a reliability-must-run contract on the units starting on April 1 and continuing until either the transmission line is constructed or another reliability solution materializes.
PJM calculated that 44% of the costs for retaining the units would be allocated to Dominion’s Virginia Electric Power and Power Co., with nearly 10% each to American Electric Power’s East zone and Commonwealth Edison.
At the Market Implementation Committee meeting the day before the TEAC meeting, PJM staff presented its new Yorktown pricing interface, which will set real-time LMPs if demand response or other load-management resources are deployed. It would be triggered on a sub-zonal basis when thermal or voltage conditions are encountered that create N-2 or N-1-1 contingencies.
At the meeting, PJM’s Independent Market Monitor Joe Bowring took issue with the plan because it allows DR to set regional prices “well above any level that generation can set it” — potentially as high as $1,800 MWh. Prices in the region are usually around $40/MWh. The interface would only be modeled in the day-ahead market if conditions are known prior to market close, and it won’t be modeled for financial transmission rights auctions.
“It’d be one thing if DR were nodal and were dispatched with the same offer caps,” Bowring said. “In a sense, the core issue is that DR can have a price and set price at $1,800 or more.”
CARY, N.C. — RTO Insider the publication has lost its wittiest voice. RTO Insider the company has lost its centrifugal force, its welcome wagon, its sage, its ultimate team player and certainly part of its soul.
Ted and his granddaughter, Charlotte in February. His comment on Facebook on the photo: “I have NO idea why this child is crying. Honest!”
Ted Caddell, RTO Insider’s longest-serving staffer — and the voice of our daily emails and frequently our social media postings — passed away overnight Tuesday, hours after helping to cover the ISO Summit here. He was 56.
Ted, who formerly lived in Wilmington, Del., and Charlottesville, Va., moved to Chapel Hill, N.C., about five years ago, following his companion, Leslie. He picked me and RTO Insider co-founder Merry Eisner up from Raleigh-Durham International Airport on Monday night. We then ate dinner with him and Leslie in Chapel Hill, where he told us how he would not eat shrimp that wasn’t North Carolina wild — no farm-raised seafood for him!
I ordered the North Carolina shrimp, and was not disappointed.
On Tuesday, he took photographs and reported on the opening session of the RTO Insider/SAS ISO Summit with PJM CEO Andy Ott, SPP CEO Nick Brown and former FERC Commissioner Tony Clark.
We expected him Wednesday morning for the second day of the summit and were concerned when he did not appear. While I was moderating the first panel of the morning, Merry got a phone call informing us of his passing.
Merry informed me of the news during a break, and I was on stage for a second panel when my phone rang with a call from Charlottesville, where I knew his brother Ray — a bandleader for whom Ted had previously worked as a roadie — lived. I handed the phone to Merry to take the call.
Since the Summit ended, I have been back in my hotel room, letting the tears flow and trying to pull myself together enough to help compose a tribute worthy of the man.
I have known Ted since the late 1990s, when I was covering electric deregulation for The Philadelphia Inquirer, and Ted, a former reporter for The News-Journal in Wilmington, was a spokesman for what was then Conectiv Energy, a Delaware-based subsidiary of Pepco Holdings Inc. There are good, bad and mediocre spokespeople, and Ted was undoubtedly one of the best. Funny, personable, self-deprecating. Even if it wasn’t a big story, I never remember a day that wasn’t better for having talked to Ted.
Ted and his granddaughter Mayble.
We hired Ted at RTO Insider in January 2014, less than a year after our launch. But I wouldn’t actually meet Ted in person until about a year later, when he was in Wilmington visiting his daughter Nicole and newborn granddaughter, Charlotte.
Ironically, as we joked over dinner Monday, we had covered the same story for our competing newspapers in 1996: the execution of Billy Bailey in Delaware, the last hanging in the U.S.
At RTO Insider, we have made it a priority to hire reporters near the headquarters of all of the ISOs and RTOs in the U.S. In Chapel Hill, Ted was nowhere near any of them. But he nonetheless made himself immediately indispensable as the first editor of our Briefs columns and as the lead reporter on many breaking news stories. He was particularly knowledgeable about generation, having done public relations for Exelon’s generation unit after leaving Conectiv.
As he wrote for his bio on our About Us page, Ted had an English literature degree from the University of Delaware, “which may explain why he’s also worked as a commercial fisherman, a roofer, landscaper and spent three years as a roadie for a swing band and orchestra.”
Ted the roadie, second from right, with Rat Pack impersonators. | Photo courtesy Ray Caddell
In January, when we launched our daily email alerts, he was our voice, and he had an immediate impact. Some people, frankly, did not appreciate his witty “lead-in” and preferred to go right to the summaries of our latest content. A handful of people were offended when he got a bit risqué or political.
They were in a decided minority. More common were comments like these:
I read five or six energy newsletters a day, which are typically quite boring. The daily opening commentary of RTO Insider’s newsletter is incredibly entertaining and I look forward to reading it every day. — Nick Esch, Smart Electric Power Alliance
Ted, thanks for really taking the “readability” factor up a notch! I look forward to your musings every day. — Joe Leingang, fuel & transport superintendent, Basin Electric Power Cooperative.
I just wanted to say that I truly enjoy Ted Caddell’s summary emails each day. I always love the random other news he provides. It’s quite hilarious. — Jen Clements, Xcel Energy
I love the changes that RTO Insider has made this year. I look forward to reading the quips and punchy, but newsworthy, introductions each day. I also enjoy that it’s not always related to our industry — a teaser of sorts before getting into the day’s news. — Tia Elliott, NRG Energy
Hey — I don’t know who comes up with these little nuggets at the beginning of the Insider. But I enjoy them tremendously. Thank you! — Marguerite Wagner, ITC Holdings
And here were the reflections of some of his colleagues:
From Bill Opalka, our former NYISO/ISO-NE correspondent, who just left us for a job with the New York State Energy Research and Development Authority:
Newsrooms are places that are full of characters, and in his day, Ted must surely had been one. He always had a quip at the ready and was full of oddball insights about the world, life and even the news. Although we were based 600 miles apart and never met face-to-face, I felt like I knew him better than most of the colleagues with whom I shared office space. He was that open and had a killer wit that got us through any crisis too.
But underneath the jokester façade, Ted was a serious newsman always looking for the next story and ready to jump in when colleagues were busy chasing other news. He’d often call with the latest scoop: “Did you hear about the Massachusetts pipeline? What’s going on at Indian Point?” And most of the time I’d reply, “Thanks, Ted, I’m already on it,” and he’d seem a little crushed that he couldn’t help.
Ted, you’ll be missed.
From Julie Gromer, our current Briefs editor, who joined us in September 2016:
The impact that Ted had on my life in such a short time period is pretty incredible.
Words cannot express my sadness. When I joined RTO Insider, Ted was the first person to reach out to welcome me to the team — and to offer any assistance that I needed. Over the past seven months, he became my online friend — checking in every day to see how I was doing, sharing news of his family and grandchildren, laughing about world events, and always offering encouragement — both in my professional and personal life.
I feel honored to have known Ted. I will miss his friendship, his “can do” attitude and his unique brand of wit.
From Tom Kleckner, our SPP and ERCOT correspondent, based in Little Rock, Ark.:
I never met Ted in person (though our paths may have crossed at one point), but I felt like I did. That may be all you need to say about Ted.
We did share direct messages and Facebook posts, and had several long phone conversations. I know I would have enjoyed Ted’s company. Check out his Facebook photos. Unless he was acting on stage, he always had a smile on his face — and an unruly head of hair that apparently didn’t get along with caps.
Ted’s writing reveals that same good nature. He was always looking for the off-beat stories that helped show what our world is really about.
From retired account executive Marge Gold:
As I sit here with my eyes swelled up, it is hard to see clearly to even type. But, clearly Ted made me smile every time I saw him on our weekly video calls, with his Starbucks in hand. He was a unique man, that I will not soon forget.
From Michael Brooks, our production/copy editor and D.C. reporter:
Ted was just as friendly as he was funny — and he was hilarious. Unfortunately, I mostly experienced that friendliness online. The Internet enables a company like ours to function even though we live in different parts of the country, but because of that, I was only able to ever meet Ted in-person once. I am truly saddened that I will not be able to have another laugh with him that isn’t online.
Suzanne Herel, our former PJM correspondent, recalled his motto:
“Every day’s a holiday, every meal’s a feast.” I miss you dreadfully, Ted.
From MISO correspondent Amanda Durish Cook:
Whenever I approached Ted with a technical question, he’d make sure to weave some humor into the explanation. He just made it delightful. I always enjoyed collecting news stories to pass to him for the repartee.
From CAISO/WECC correspondent Robert Mullin:
With your co-workers spread across the country, you can miss out on some aspects of easy friendship that can develop with people you happen to share space with seven or eight hours a day. Ted was someone who sought to close that distance. When I started with RTO Insider, he would call just to check in, see how things were going. There was usually nothing specific to talk about, and during those conversations I learned a little about his life, his partner, Leslie, his kids, and his two young granddaughters Mayble and Charlotte — just a bit younger than my own son.
Let me direct my last comments to you, Mayble and Charlotte: your grandfather was sharp-witted, blunt, warm-hearted — irrepressible in his opinions, but thoughtful. Salt of the earth. I wish I could’ve had more time to get to know him better. I wish you could’ve, too. I hope you carry a little bit of him with you into the future.
Ted often returned to Wilmington to visit his daughter, Nicole Wample, and his beloved granddaughters, Mayble, 3, and Charlotte, who turns 2 on Friday. He is also survived by his partner, Leslie Udry; his mother, Sally, of Avon Park, Fla.; his older brother, Ray, of Charlottesville, Va.; and his son, Michael, of Philadelphia.
Memorial arrangements are pending. We will update this story when they are available.
“He loved his job,” said Ray. “It was good for him.”
CAISO market operators are preparing to deal with an inevitable flood of energy oversupply this spring, when unusually high levels of hydroelectric output are expected to compound the impact of growing solar penetration on the California grid.
One likely outcome: forced reductions in self-scheduled power deliveries throughout the season.
The ISO is already experiencing the effects of oversupply — in the form of economic curtailments — months ahead of the spring melt in the Sierra Nevada mountains, where snowpack in some areas stands at more than 175% of normal, according to the California Department of Water Resources.
“Altogether, [we] can see that wind, solar and hydro are making up a lot of generation in the first two months of the year,” Guillermo Bautista Alderete, CAISO director of market analysis and forecasting, said during a March 14 Market Performance and Planning Forum (see graph).
Hydroelectric output in CAISO this winter has already exceeded that for recent spring periods when California was subject to severe drought conditions. | CAISO
“If you just compare against the same profile for one year ago, you can see that we are well over the historical levels [for hydro] — and this is just January and February,” Bautista Alderete said.
And while hydro has so far been the biggest contributor to the mix, solar output will become an increasing factor, with the longer days and more intense periods of sunlight in spring and summer.
“The big story here is the year-over-year change that we’ve seen going back to 2013, when we didn’t have a lot of solar on the system,” said Gabe Murtaugh, a senior analyst with the ISO’s Department of Market Monitoring.
Murtaugh pointed out that 2015 was the first year in which large-scale solar became the most significant source of renewable power on the ISO system — with output last year surging again by 33% to more than 20,000 GWh as installed capacity climbed to about 9 GW.
That capacity figure doesn’t include rooftop installations, which the ISO estimates stand at 5 to 6 GW — or about 12 to 15% of average system load, according to Amber Motley, CAISO’s manager of short-term forecasting.
“Current solar capacity is capable of increasing oversupply risk without factoring in wind and hydro,” Motley noted in her presentation to the forum.
The evidence is already coming in. Curtailments have been on the rise this winter, with about 60,000 MWh of solar output being cut off in February — the largest amount for any month since the beginning of 2016.
Bautista Alderete explained that, under its current staged approach to oversupply, CAISO first exhausts its regulation service, which ramps down output from participating resources, followed by economic curtailment of price takers in the market.
“You keep going through the bid stack to the point until you find the balance of supply and demand,” he said.
Once economic bids are spent, the ISO begins to curtail self-scheduled energy deliveries.
“So you exhaust your regulation before you cut into the self-schedules?” asked Seth Cochran, manager of market affairs and origination at DC Energy.
“This is something we’re going to revisit,” responded Mark Rothleder, CAISO vice president of market quality and renewable integration. “If, for short periods of time, we’re going into the regulation stack, it’s OK. If we’re persistently going into the regulation stack, that’s a problem.”
He said the ISO is considering reducing its reliance on regulation during oversupply periods, a move that would require more frequent curtailment of self-schedules.
Rothleder speculated that on a warm, sunny and breezy weekend day in the spring when hydro is spilling at a high rate, CAISO would move quickly through its bid stack of an estimated 1,500 to 2,000 MW of curtailable renewables and begin to confront reductions in self-schedules.
“The next question is: How far?” he said.
To illustrate the potential scope of reductions, Rothleder highlighted system conditions on the previous Sunday, March 12, when the ISO saw its net load (which represents total system load minus output for variable renewable generation) fall to about 10.9 GW with 15 GW of available generation. With a maximum of 2 GW of economic bids poised for curtailment, the balance, he said, would come from self-schedules.
Bautista Alderete said CAISO is seeking to be “proactive” in alleviating the oversupply problem, pointing to Motley’s work to improve short-term forecasting of oversupply conditions.
Motley has been seeking to discern indicators of potential oversupply in the day-ahead market.
One such indicator: negative pricing in the energy component of the LMP.
Another: a forecast of about 5 GW of renewable generation paired with a load forecast of about 25 GW — an average for this time of year — leaving a net load of 20 GW.
Even with no wind output, the 9 GW of solar on the system has the potential to push the system into oversupply under those load conditions.
Motley said historical hydro schedules, while factored into the forecast, will not be the most reliable indicators of oversupply because of the year-to-year difference in hydro conditions. Hydro operators are likely to have less flexibility to ramp down output this spring with increased flows.
The forecasts might occasionally compel the ISO to reach out to market participants outside normal market channels.
“On days when we go below 20,000 MW [in net load] on average, we may have a phone call [with scheduling coordinators] … to state our oversupply risks,” Motley said. “We don’t want to use those all the time, because some of these factors are going to be there every weekend, but when we see more extremes, we may use that coordination phone call.”
